US20100050762A1 - Methods and apparatus to perform pressure testing of geological formations - Google Patents
Methods and apparatus to perform pressure testing of geological formations Download PDFInfo
- Publication number
- US20100050762A1 US20100050762A1 US12/202,868 US20286808A US2010050762A1 US 20100050762 A1 US20100050762 A1 US 20100050762A1 US 20286808 A US20286808 A US 20286808A US 2010050762 A1 US2010050762 A1 US 2010050762A1
- Authority
- US
- United States
- Prior art keywords
- pressure
- interval
- pump
- formation
- guard
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Granted
Links
- 238000012360 testing method Methods 0.000 title claims abstract description 71
- 230000015572 biosynthetic process Effects 0.000 title claims abstract description 60
- 238000000034 method Methods 0.000 title claims abstract description 43
- 238000005755 formation reaction Methods 0.000 title abstract description 53
- 239000012530 fluid Substances 0.000 claims abstract description 27
- 238000007789 sealing Methods 0.000 claims abstract description 9
- 238000005553 drilling Methods 0.000 description 19
- 239000000523 sample Substances 0.000 description 17
- 238000005070 sampling Methods 0.000 description 11
- 238000012545 processing Methods 0.000 description 4
- 238000003860 storage Methods 0.000 description 4
- 238000004519 manufacturing process Methods 0.000 description 3
- 238000005259 measurement Methods 0.000 description 3
- 238000004891 communication Methods 0.000 description 2
- 238000005520 cutting process Methods 0.000 description 2
- 230000002706 hydrostatic effect Effects 0.000 description 2
- 230000003287 optical effect Effects 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 239000000706 filtrate Substances 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 230000009545 invasion Effects 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 238000009931 pascalization Methods 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 230000002787 reinforcement Effects 0.000 description 1
- 230000035939 shock Effects 0.000 description 1
- 230000000087 stabilizing effect Effects 0.000 description 1
- 230000001360 synchronised effect Effects 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/12—Packers; Plugs
- E21B33/124—Units with longitudinally-spaced plugs for isolating the intermediate space
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
- E21B49/008—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by injection test; by analysing pressure variations in an injection or production test, e.g. for estimating the skin factor
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
- E21B49/08—Obtaining fluid samples or testing fluids, in boreholes or wells
- E21B49/087—Well testing, e.g. testing for reservoir productivity or formation parameters
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
- E21B49/08—Obtaining fluid samples or testing fluids, in boreholes or wells
- E21B49/087—Well testing, e.g. testing for reservoir productivity or formation parameters
- E21B49/088—Well testing, e.g. testing for reservoir productivity or formation parameters combined with sampling
Definitions
- This disclosure relates generally to geological formations and, more particularly, to methods and apparatus to perform pressure testing of geological formations.
- Wells are generally drilled into the ground to recover natural deposits of hydrocarbons and/or other desirable materials trapped in geological formations in the Earth's crust.
- a well is drilled into the ground and/or directed to a targeted geological location and/or geological formation by a drilling rig at the Earth's surface.
- Data collected from pressure testing a geological formation can be used to determine one or more properties of the geological formation and/or a formation fluid present in the geological formation.
- Example methods and apparatus to perform pressure testing of geological formations are disclosed.
- a disclosed example method includes positioning a testing tool in a wellbore formed in the geological formation, sealing a sample interval around the testing tool, sealing a first guard interval around the testing tool and adjacent to the sample interval, reducing a first pressure in the sample interval, reducing a second pressure in the first guard interval, maintaining a volume of a first chamber fluidly coupled to the sample interval during a time interval, and measuring a plurality of pressure data for a fluid captured in the first chamber during the time interval.
- a disclosed example downhole tool for pressure testing a geological formation includes first and second packers to form an inner interval around the testing tool, a third packer to seal a first outer interval around the testing tool adjacent to the inner interval, a first pump to reduce a first pressure in the inner interval, a second pump to reduce a second pressure in the first outer interval, and a pressure gauge to measure a plurality of pressure data for a fluid captured in the inner interval while the second pressure is reduced and a volume of the inner interval is maintained.
- FIG. 1 illustrates an example wellsite drilling system within which the example methods and apparatus described herein may be implemented.
- FIG. 2 illustrates an example manner of implementing a logging while drilling (LWD) module for the example wellsite drilling system of FIG. 1 .
- LWD logging while drilling
- FIG. 3 illustrates an example manner of implementing the pressure testing system of FIG. 2 .
- FIG. 4 is a graph characterizing an example operation of the example pumping system of FIG. 2 .
- FIG. 5 illustrates another example manner of implementing the pressure testing system of FIG. 2 .
- FIG. 6 is a flowchart of an example process that may be executed by, for example, a processor to perform pressure testing of a geological formation.
- FIG. 7 is a schematic illustration of an example processor platform that may be used and/or programmed to carry out the example process of FIG. 6 to implement any of all of the example methods and apparatus described herein.
- the example methods and apparatus disclosed herein use multiple packers to mechanically stabilize a packed and/or sealed-off section of the wellbore (i.e., an inner interval, a sampling interval, etc.) in which pressure testing and/or fluid sampling operations may be performed.
- a packed and/or sealed-off section of the wellbore i.e., an inner interval, a sampling interval, etc.
- pressure testing and/or fluid sampling operations may be performed.
- guard intervals are formed on opposite sides of the sampling interval by the use of additional outer packers.
- the hydraulic pressure in the guard intervals may be controlled and/or maintained to reduce the differential pressure(s) across the inner packer elements that form the sampling interval during, for example, a pressure drawdown and a subsequent pressure buildup test.
- a low pressure-differential may be maintained across the inner packers.
- the difference between the wellbore pressure (i.e., hydrostatic pressure) and the drawdown pressure may be distributed across the guard intervals and the sampling interval to facilitate pressure testing in wellbores having high hydrostatic pressures.
- example methods and apparatus are described herein with reference to so-called “sampling-while-drilling,” “logging-while-drilling,” and/or “measuring-while drilling” operations, the example methods and apparatus may, additionally or alternatively, be used to perform pressure testing of geological formations during a wireline sampling operation.
- FIG. 1 illustrates an example wellsite drilling system that can be employed onshore and/or offshore.
- a borehole 11 is formed in one or more subsurface formations F by rotary and/or directional drilling.
- a drill string 12 is suspended within the borehole 11 and has a bottom hole assembly (BHA) 100 having an optional drill bit 105 at its lower end.
- a surface system includes a platform and derrick assembly 10 positioned over the borehole 11 .
- the example derrick assembly 10 of FIG. 1 includes a rotary table 16 , a kelly 17 , a hook 18 and a rotary swivel 19 .
- the drill string 12 is rotated by the rotary table 16 , energized by means not shown, which engages the kelly 17 at the upper end of the drill string 12 .
- the example drill string 12 is suspended from the hook 18 , which is attached to a traveling block (not shown), and through the kelly 17 and the rotary swivel 19 , which permits rotation of the drill string 12 relative to the hook 18 .
- a top drive system could be used.
- the surface system further includes drilling fluid or mud 26 stored in a pit 27 formed at the well site.
- a pump 29 delivers the drilling fluid 26 to the interior of the drill string 12 via a port in the swivel 19 , causing the drilling fluid to flow downwardly through the drill string 12 as indicated by the directional arrow 8 .
- the drilling fluid 26 exits the drill string 12 via ports in the drill bit 105 , and then circulates upwardly through the annulus region between the outside of the drill string 12 and the wall of the borehole 11 , as indicated by the directional arrows 9 .
- the drilling fluid 26 lubricates the drill bit 105 , carries formation cuttings up to the surface as it is returned to the pit 27 for recirculation, and creates a mudcake layer on the walls of the borehole 11 .
- the example BHA 100 of FIG. 1 includes, among other things, any number and/or type(s) of logging-while-drilling (LWD) modules (two of which are designated at reference numerals 120 and 120 A) and/or measuring-while-drilling (MWD) modules (one of which is designated at reference numeral 130 ), a roto-steerable system or mud motor 150 , and the optional drill bit 105 .
- LWD logging-while-drilling
- MWD measuring-while-drilling
- the example LWD modules 120 and 120 A of FIG. 1 are each housed in a special type of drill collar, as it is known in the art, and each contain any number of logging tools and/or fluid sampling devices.
- the example LWD modules 120 , 120 A include capabilities for measuring, processing, and/or storing information, as well as for communicating with surface equipment, such as a logging and control computer 160 via, for example, the MWD module 130 .
- An example LWD module 200 having four packers to improve the accuracy and/or conditions in which pressure testing of the geological formation F may be performed is described below in connection with FIG. 2 .
- Example manners of implementing a pressure testing system 220 ( FIG. 2 ) for any of the LWD modules 120 , 120 A, 200 are described below in connection with FIGS. 3 and 5 .
- the example MWD module 130 of FIG. 1 is also housed in a special type of drill collar and contains one or more devices for measuring characteristics of the drill string 12 and/or the drill bit 105 .
- the example MWD tool 130 further includes an apparatus (not shown) for generating electrical power for use by the downhole system.
- Example devices to generate electrical power include, but are not limited to, a mud turbine generator powered by the flow of the drilling fluid, and a battery system.
- Example measuring devices include, but are not limited to, a weight-on-bit measuring device, a torque measuring device, a vibration measuring device, a shock measuring device, a stick slip measuring device, a direction measuring device, and an inclination measuring device.
- FIG. 2 is a schematic illustration of an example manner of implementing either or both of the example LWD modules 120 and 120 A of FIG. 1 . While either of the example LWD modules 120 and 120 A of FIG. 1 may be implemented by the example device of FIG. 2 , for ease of discussion, the example device of FIG. 2 will be referred to as LWD module 200 .
- the example LWD module 200 of FIG. 2 may be used to perform, among other things, pressure testing of a geological formation F.
- the example LWD module 200 is attached to the drill string 12 ( FIG. 1 ) driven by the rig 10 to form the wellbore or borehole 11 .
- the LWD module 200 includes a passage (not shown) to permit drilling mud to be pumped through the LWD module 200 to remove cuttings away from a drill bit.
- the example LWD module 200 of FIG. 2 includes packers 210 , 211 , 212 and 213 .
- the example packers 210 - 213 of FIG. 2 are inflatable elements that encircle the generally circularly shaped LWD 200 .
- the example intervals 205 - 207 of FIG. 2 likewise encircle the LWD 200 .
- the example inner pair of packers 210 and 211 form the inner and/or sampling interval 205 in which pressure testing of the geological formation F is performed.
- the example packers 210 - 213 of FIG. 2 have a height of 1.5 feet and a spacing of 3 feet. However, other size packers and/or packer spacing(s) may be used depending on an expected mud filtrate invasion depth, and/or a desired formation fluid cleanup and/or production performance.
- the example LWD module 200 of FIG. 2 includes ports 225 , 226 and 227 for respective ones of the intervals 205 - 207 .
- the example pressure testing system 220 of FIG. 2 is able to pump fluid from the sample and/or inner interval 205 via the port 225 to perform a cleanup or sampling operation of the sample interval 205 (e.g., lift and/or remove mudcake), and/or to drawdown the pressure in the sample interval 205 and measure subsequent pressure buildup data.
- the example pressure testing system 220 is also able to draw fluid out of and/or push fluid into the guard intervals 206 and 207 to adjust, control and/or maintain pressure(s) in the guard intervals 206 and 207 .
- the pressure testing system 220 reduces the pressure in the guard intervals 206 and 207 to approximately the formation pressure (or a pressure between the formation pressure and the wellbore pressure) while the sample interval 205 is being drawn down to perform a pressure buildup test.
- the pressure differential experienced by the inner packers 210 and 211 is reduced to less than the pressure differential that would be experienced by the packers 210 and 211 were the outer packers 212 and 213 not present, inflated and/or implemented.
- the pressure testing system 220 of FIG. 2 maintains the pressures in the guard intervals 206 and 207 to be substantially equal to (or having a fixed offset from) the pressure in the inner interval 205 .
- the inner packers 210 and 211 are less susceptible to mechanical instability (e.g., creeping, sliding and/or deformation), thereby improving the accuracy of the subsequent pressure buildup data.
- the example inner packers 210 and 211 of FIG. 2 are subjected to lower differential pressures they may be implemented using simpler packer structures (e.g. shorter packers, packers having less or none reinforcement structures such as cables, etc.). The use of shorter and/or simpler packer structures may be advantageous to reduce the overall length of the LWD module 200 .
- Example manners of implementing the example pressure testing system 220 of FIG. 2 is described below in connection with FIGS. 3 and 5 .
- the example pressure testing system 220 of FIG. 2 is also fluidly coupled to a port 228 located below the example outer packer 213 .
- the example port 228 of FIG. 2 is directly exposed to the fluid(s) present in the wellbore 11 .
- the example port 228 may, alternatively, be located above the example outer packer 212 .
- the port 228 may be fluidly coupled to an additional port (not shown) located above the packer 212 via a bypass flowline of the LWD module 200 (not shown).
- the second can be used to balance the pressure of the portion of the wellbore 11 located above the packer 212 with the pressure of the portion of the wellbore 11 located below the packer 213 , and/or to allow fluid to be moved between any of the intervals 206 - 207 and the wellbore 11 via a bypass flowline of the LWD module 200 (not shown).
- one or more probes having pretest capabilities may be implemented to perform formation pressure and/or mobility measurements in one or more of the intervals 206 and 207 , below the example outer packer 213 and/or above the example outer packer 212 .
- Such probes may be used to obtain values representative of formation parameters in a substantially shorter time period than when using a packer interval.
- Formation parameter values obtained with the probe(s) may be used by example pressure testing system 220 for example to maintain the pressures in the guard intervals 206 and 207 to be substantially equal to (or having a fixed offset from) the formation pressure.
- Example probes and methods to use the same are described in U.S. Pat. No.
- pressure values obtained with the probe(s) may be used to determine propagation properties of pressure pulses in the formation.
- Example manners of determining propagation properties of pressure pulses in the formation are taught for example in U.S. Pat. No. 4,936,139, entitled “Downhole Method for Determination of Formation Properties,” and issued on Jun. 26, 1990.
- FIG. 3 illustrates an example manner of implementing the example pressure testing system 220 of FIG. 2 .
- the example pressure testing system 220 of FIG. 2 includes any type of pump 305 .
- the example pump 305 of FIG. 3 pumps fluid from the port 225 into, for example, a sample container and/or bottle, the wellbore 11 (e.g., via a bypass flowline (not shown)), and/or a fluid analysis module.
- the example pump 305 may be used to pump fluid from the inner interval 205 to drawdown the pressure P S of the inner interval 205 to initiate a pressure buildup test.
- FIG. 3 illustrates an example manner of implementing the example pressure testing system 220 of FIG. 2 .
- the example pressure testing system 220 of FIG. 2 includes any type of pump 305 .
- the example pump 305 of FIG. 3 pumps fluid from the port 225 into, for example, a sample container and/or bottle, the wellbore 11 (e.g., via a bypass flowline (not shown)), and/
- the inner interval pressure P S is reduced by the pump 305 to a pressure that is less than the formation pressure P F .
- the pump 305 operates until a specified amount of reservoir fluid has been pumped. Additionally or alternatively, the pump 305 operates until the drawdown pressure is reached, the pump 305 is stopped, and the inner interval pressure P S is measured while it builds backup towards the formation pressure P F , and while the volume(s) of any flowlines and/or chambers fluidly coupled to the port 225 are held constant.
- the example pressure testing system 220 of FIG. 2 includes any type of pressure gauge 310 .
- the example pressure testing system 220 of FIG. 3 includes any type of pump 315 .
- the example pump 315 of FIG. 3 is controllable to pump fluid into and/or out of the guard intervals 206 and 207 to increase and/or decrease the pressure in the guard intervals 206 and 207 , respectively.
- An example pump 315 includes a hydraulic piston 320 to adjust the volume in a chamber 325 fluidly coupled to the ports 226 and 227 .
- the example pressure testing system 220 of FIG. 2 includes any type of pressure gauge 330 .
- the example pressure testing system 220 of FIG. 2 includes any type of pressure gauge 335 .
- a single pump is used to implement the pump 305 and the pump 315 .
- the example pressure testing system 220 of FIG. 3 includes a controller 340 .
- the example controller 340 of FIG. 3 controls the example pump 305 and piston 320 to initiate a pressure buildup test, and measures the pressure in the inner interval 205 during the subsequent pressure buildup phase via the example pressure gauge 310 .
- the example controller 340 also controls the inflation and deflation of the example packers 210 - 213 .
- the example controller 340 of FIG. 3 is implemented by any type of general-purpose processor, processor core, and/or microcontroller.
- the example controller 340 may be implemented by one or more circuit(s), programmable processor(s), application specific integrated circuit(s) (ASIC(s)), programmable logic device(s) (PLD(s)) and/or field programmable logic device(s) (FPLD(s)), etc., and/or any combination of hardware, firmware and/or software.
- ASIC application specific integrated circuit
- PLD programmable logic device
- FPLD field programmable logic device
- the example controller 340 ( FIG. 3 ) activates the pump 305 to reduce the inner interval pressure P S from the wellbore pressure P W to a pressure less than the formation pressure P F . While the inner interval pressure P S is being reduced, the example controller 340 adjusts the position of the piston 320 to adjust the guard interval pressure P G to a desired and/or target pressure.
- the guard interval pressure P G may be adjusted in accordance with any number of pressure management strategies. For example, the guard interval pressure P G may be reduced to the formation pressure P F (e.g. estimated from a measurement performed by a probe).
- the pressure differentials experienced by each of the inner packers 210 and 211 is substantially zero at the end of the pressure buildup test, while the pressure differentials experienced by the outer packers 212 and 213 are substantially the difference between the wellbore pressure P W and the formation pressure P F at the end of the pressure buildup test.
- the guard interval pressure P G is adjusted to a pressure between the wellbore pressure P W and the formation pressure P F to distribute the pressure difference across the inner packers 210 and 211 and the outer packers 212 and 213 .
- the example LWD module 200 can operate in a wellbore having a higher hydrostatic pressure to drawdown pressure difference than can be withstood by a single pair of inner packers 210 and 211 and/or the pump 305 .
- the example controller 340 can determine how much to reduce the pressure P G of the guard intervals 206 and 207 based on the wellbore pressure P W measured by the pressure gauge 335 and a desired drawdown pressure. For example, for a large wellbore to drawdown pressure difference, the example controller 340 distributes the pressure difference across the outer packers 212 and 213 and the inner packers 210 and 211 . Otherwise, the example controller 340 adjusts the guard interval pressure P G to be substantially equal to the formation pressure P F .
- the controller 340 starts measuring pressure buildup data in the inner interval 205 using the pressure gauge 310 .
- FIG. 5 illustrates another example manner of implementing the example pressure testing system 220 of FIG. 2 .
- elements of the example pressure testing system 220 of FIG. 5 are similar or identical to those discussed above in connection with FIG. 3 , the descriptions of those similar or identical elements are not repeated here. Instead, similar or identical elements are illustrated with identical reference numerals in FIGS. 3 and 5 , and the interested reader is referred back to the descriptions presented above in connection with FIG. 3 for a complete description of those like numbered elements.
- the example pressure testing system 220 of FIG. 5 includes pressure controllers 505 and 510 for respective ones of the guard intervals 206 and 207 .
- the example pressure controller 505 of FIG. 5 actively controls the pump 315 to maintain the guard interval pressure P G1 of the guard interval 206 based on the inner interval pressure P S and the wellbore pressure P W .
- the pressure controller 505 adapts and/or maintains the guard interval pressure P G1 to be substantially equal to the inner interval pressure P S to reduce the mechanical stresses experienced by the inner packer 210 .
- the example controller 505 adapts the guard interval pressure P G1 to distribute the pressure difference between the outer packer 212 and the inner packer 210 .
- the pressure P G1 of the guard interval 206 is measured by the example pressure gauge 330 .
- the example pressure controller 510 of FIG. 5 actively controls a pump 315 B, which is substantially identical to the example pump 315 , to maintain the guard interval pressure P G2 of the second guard interval 207 based on the inner interval pressure P S and the wellbore pressure P W .
- the pressure P G2 of the guard interval 207 is measured by a pressure gauge 330 B, which is substantially identical to the pressure gauge 330 . While in some examples, the pressures P G1 and P G1 are maintained at substantially the same pressure, the pressures P G1 and P G1 may be maintained at different pressures.
- independent control of the pressure P G1 in the first guard interval 206 and the pressure P G2 in the second guard interval 207 may be beneficial when one of the outer packers 212 , 213 experiences mechanical instability (e.g., creeping, sliding and/or deformation).
- the pressure in the corresponding guard intervals 206 or 207 may require adjustment to minimize the impact of the mechanical instability of the outer packer 212 , 213 on the pressure P G in the testing interval 205 .
- the example pressure controllers 505 and 510 of FIG. 5 are implemented by any type of general-purpose processor, processor core, and/or microcontroller. Alternatively, the example pressure controllers 505 and 510 may be implemented by one or more circuit(s), programmable processor(s), ASIC(s), PLD(s) and/or FPLD(s), etc., and/or any combination of hardware, firmware and/or software.
- the example controller 340 of FIG. 5 activates and/or deactivates the pressure controllers 505 and 510 .
- FIGS. 3 and 5 While example manners of implementing the example pressure testing system 220 of FIG. 2 have been illustrated in FIGS. 3 and 5 , one or more of the elements, controllers and/or devices illustrated in FIGS. 3 and/or 5 may be combined, divided, re-arranged, omitted, eliminated, and/or implemented in any other way.
- the example pressure controller 505 could be implemented in the example pressure control system 220 of FIG. 2 to adapt, control and/or maintain the pressure in both of the guard intervals 206 and 207 via the pump 315 .
- a pressure testing system and/or LWD module may include elements, controllers and/or devices instead of, or in addition to, those illustrated in FIGS. 3 and/or 5 , and/or may include more than one of any or all of the illustrated elements, controllers and/or devices.
- FIG. 6 illustrates an example process that may be carried out to perform pressure testing of a geological formation.
- the example process of FIG. 6 may be carried out by a processor, a controller and/or any other suitable processing device.
- the process of FIG. 6 may be embodied in coded instructions stored on a tangible machine and/or computer-readable medium such as a flash memory, a CD, a DVD, a floppy disk, a read-only memory (ROM), a random-access memory (RAM), a programmable ROM (PROM), an electronically-programmable ROM (EPROM), and/or an electronically-erasable PROM (EEPROM), an optical storage disk, an optical storage device, a magnetic storage disk, a magnetic storage device, and/or any other tangible medium, which can be accessed, read and/or executed by a processor, a general purpose or special purpose computer or other machine with a processor (e.g., the example processor platform P 100 discussed below in connection with FIG.
- a processor e.g., the example
- FIG. 6 may be implemented using any combination(s) of circuit(s), ASIC(s), PLD(s), FPLD(s), discrete logic, hardware, firmware, etc.
- some or all of the example process of FIG. 6 may be implemented manually or as any combination of any of the foregoing techniques, for example, any combination of firmware, software, discrete logic and/or hardware.
- the example operations of FIG. 6 are described with reference to the flowchart of FIG. 6 , many other methods of implementing the operations of FIG. 6 may be employed. For example, the order of execution of the blocks may be changed, and/or one or more of the blocks described may be changed, eliminated, sub-divided, or combined. Additionally, any or all of the example process of FIG. 6 may be carried out sequentially and/or carried out in parallel by, for example, separate processing threads, processors, devices, discrete logic, circuits, etc.
- the example process of FIG. 6 begins with the example LWD module 200 of FIG. 2 being positioned in a wellbore (block 605 ).
- the example controller 340 ( FIGS. 3 and 5 ) inflates the packers 210 - 213 to seal and/or form the intervals 205 - 207 (block 610 ).
- the inner packers 210 and 211 are inflated prior to the outer packers 212 and 213 , however, all of the packers 210 - 213 may alternatively be inflated essentially simultaneously.
- the controller 340 collects pressure data to estimate the wellbore pressure P W and the formation pressure P F .
- the wellbore pressure P W may be obtained via the pressure sensor 335 ( FIGS. 3 and 5 ), and the controller 340 may initiate a pretest using a probe (not shown) to estimate the formation pressure P F .
- prior knowledge of the formation F e.g. from a remotely performed pressure test, a pressure gradient, etc. are used estimate the formation pressure P F .
- the controller 340 activates the pump 305 to, for example, perform initial cleanup, and/or mudcake removal in the inner interval 205 (block 615 ).
- a formation pressure estimation may also be obtained at block 615 by detecting a mudcake breach and/or by permitting the pressure P S in the interval 205 to stabilize after mudcake removal.
- the controller 340 activates the pump 305 to drawdown the pressure P S of the inner interval 205 (block 620 ).
- the controller 340 of FIG. 35 controls the pump 315 or activates the pressure controllers 505 and 510 ( FIG. 5 ) to adjust, set and/or otherwise reduce the pressures P G1 and/or P G2 of the guard intervals 206 and 207 (block 625 ).
- the example controller 340 controls the pump 315 to adjust, set and/or otherwise reduce the pressure P G of the guard intervals 206 and 207 .
- the pressures P G1 and/or P G2 are controlled based on an estimate of the formation pressure P F , as well as the wellbore pressure P W .
- the pressures P G1 and/or P G2 are preferably maintained above the formation pressure P F in order to minimize the risk of establishing a hydraulic communication between one of the outer intervals 206 or 207 and the formation F ( FIG. 2 ), which could have negative effect on the quality of the pressure buildup data and their interpretation.
- the drawdown and the guard interval pressure reductions may be performed in parallel to maintain the mechanical stability of the inner packers 210 - 211 .
- the controller 340 then freezes and/or fixes the volume of any flowlines and/or chambers fluidly coupled to the sample interval 205 (block 630 ).
- the controller 340 measures the pressure buildup data using the pressure gauge 310 , see FIG. 3 (block 640 ). If there are pressure controllers 505 , 510 available for the guard intervals 206 and 207 (block 635 ), the controller 340 measures the pressure buildup data using the pressure gauge 310 while the pressure controllers 505 , 510 maintain the guard interval pressures P G1 and P G2 , see FIG. 5 (block 645 ).
- the controller 340 stores the measured pressure buildup data (block 650 ), and de-activates the pressure controllers 505 and 510 (if present) and deflates the packers (block 655 ). Control then exits from the example process of FIG. 6 .
- the controller 340 stores the measured pressure buildup data (block 650 ), and de-activates the pressure controllers 505 and 510 (if present) and deflates the packers (block 655 ). Control then exits from the example process of FIG. 6 .
- the controller 340 stores the measured pressure buildup data (block 650 ), and de-activates the pressure controllers 505 and 510 (if present) and deflates the packers (block 655 ). Control then exits from the example process of FIG. 6 .
- the controller 340 stores the measured pressure buildup data (block 650 ), and de-activates the pressure controllers 505 and 510 (if present) and deflates the packers (block 655 ). Control then exits from the example process of FIG
- FIG. 7 is a schematic diagram of an example processor platform P 100 that may be used and/or programmed to implement any or all of the example methods and apparatus disclosed herein.
- the processor platform P 100 can be implemented by one or more general-purpose processors, processor cores, microcontrollers, etc.
- the processor platform P 100 of the example of FIG. 7 includes at least one general-purpose programmable processor P 105 .
- the processor P 105 executes coded instructions P 110 and/or P 112 present in main memory of the processor P 105 (e.g., within a RAM P 115 and/or a ROM P 120 ).
- the processor P 105 may be any type of processing unit, such as a processor core, a processor and/or a microcontroller.
- the processor P 105 may execute, among other things, the example process of FIG. 6 to perform pressure testing of a geological formation.
- the processor P 105 is in communication with the main memory (including a ROM P 120 and/or the RAM P 115 ) via a bus P 125 .
- the RAM P 115 may be implemented by dynamic random-access memory (DRAM), synchronous dynamic random-access memory (SDRAM), and/or any other type of RAM device(s), and ROM may be implemented by flash memory, EPROM, EEPROM, a CD, a DVD and/or any other desired type of memory device(s). Access to the memory P 115 and the memory P 120 may be controlled by a memory controller (not shown).
- the memory P 115 may be used to store pressure buildup data.
- the processor platform P 100 also includes an interface circuit P 130 .
- the interface circuit P 130 may be implemented by any type of interface standard, such as an external memory interface, serial port, general-purpose input/output, etc.
- One or more input devices P 135 and one or more output devices P 140 are connected to the interface circuit P 130 .
- the input devices P 135 may be used to collect and/or receive pressure data from a pressure gauge.
- the output devices P 140 may be use to control and/or activate a pump.
Landscapes
- Mining & Mineral Resources (AREA)
- Engineering & Computer Science (AREA)
- Life Sciences & Earth Sciences (AREA)
- Geology (AREA)
- Physics & Mathematics (AREA)
- Geochemistry & Mineralogy (AREA)
- Fluid Mechanics (AREA)
- Environmental & Geological Engineering (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Analytical Chemistry (AREA)
- Chemical & Material Sciences (AREA)
- Geophysics (AREA)
- Investigating Strength Of Materials By Application Of Mechanical Stress (AREA)
- Measuring Fluid Pressure (AREA)
- Examining Or Testing Airtightness (AREA)
- Investigation Of Foundation Soil And Reinforcement Of Foundation Soil By Compacting Or Drainage (AREA)
Abstract
Description
- This disclosure relates generally to geological formations and, more particularly, to methods and apparatus to perform pressure testing of geological formations.
- Wells are generally drilled into the ground to recover natural deposits of hydrocarbons and/or other desirable materials trapped in geological formations in the Earth's crust. A well is drilled into the ground and/or directed to a targeted geological location and/or geological formation by a drilling rig at the Earth's surface. Data collected from pressure testing a geological formation can be used to determine one or more properties of the geological formation and/or a formation fluid present in the geological formation.
- Example methods and apparatus to perform pressure testing of geological formations are disclosed. A disclosed example method includes positioning a testing tool in a wellbore formed in the geological formation, sealing a sample interval around the testing tool, sealing a first guard interval around the testing tool and adjacent to the sample interval, reducing a first pressure in the sample interval, reducing a second pressure in the first guard interval, maintaining a volume of a first chamber fluidly coupled to the sample interval during a time interval, and measuring a plurality of pressure data for a fluid captured in the first chamber during the time interval.
- A disclosed example downhole tool for pressure testing a geological formation includes first and second packers to form an inner interval around the testing tool, a third packer to seal a first outer interval around the testing tool adjacent to the inner interval, a first pump to reduce a first pressure in the inner interval, a second pump to reduce a second pressure in the first outer interval, and a pressure gauge to measure a plurality of pressure data for a fluid captured in the inner interval while the second pressure is reduced and a volume of the inner interval is maintained.
-
FIG. 1 illustrates an example wellsite drilling system within which the example methods and apparatus described herein may be implemented. -
FIG. 2 illustrates an example manner of implementing a logging while drilling (LWD) module for the example wellsite drilling system ofFIG. 1 . -
FIG. 3 illustrates an example manner of implementing the pressure testing system ofFIG. 2 . -
FIG. 4 is a graph characterizing an example operation of the example pumping system ofFIG. 2 . -
FIG. 5 illustrates another example manner of implementing the pressure testing system ofFIG. 2 . -
FIG. 6 is a flowchart of an example process that may be executed by, for example, a processor to perform pressure testing of a geological formation. -
FIG. 7 is a schematic illustration of an example processor platform that may be used and/or programmed to carry out the example process ofFIG. 6 to implement any of all of the example methods and apparatus described herein. - Certain examples are shown in the above-identified figures and described in detail below. In describing these examples, like or identical reference numbers may be used to identify common or similar elements. The figures are not necessarily to scale and certain features and certain views of the figures may be shown exaggerated in scale or in schematic for clarity and/or conciseness.
- The example methods and apparatus disclosed herein use multiple packers to mechanically stabilize a packed and/or sealed-off section of the wellbore (i.e., an inner interval, a sampling interval, etc.) in which pressure testing and/or fluid sampling operations may be performed. By mechanically stabilizing the sampling interval, the pressure buildup characteristics of a geological formation can be more accurately measured, computed and/or otherwise determined. To stabilize the sampling interval, guard intervals are formed on opposite sides of the sampling interval by the use of additional outer packers. The hydraulic pressure in the guard intervals may be controlled and/or maintained to reduce the differential pressure(s) across the inner packer elements that form the sampling interval during, for example, a pressure drawdown and a subsequent pressure buildup test. For example, a low pressure-differential may be maintained across the inner packers. Additionally or alternatively, the difference between the wellbore pressure (i.e., hydrostatic pressure) and the drawdown pressure may be distributed across the guard intervals and the sampling interval to facilitate pressure testing in wellbores having high hydrostatic pressures.
- While example methods and apparatus are described herein with reference to so-called “sampling-while-drilling,” “logging-while-drilling,” and/or “measuring-while drilling” operations, the example methods and apparatus may, additionally or alternatively, be used to perform pressure testing of geological formations during a wireline sampling operation.
-
FIG. 1 illustrates an example wellsite drilling system that can be employed onshore and/or offshore. In the example wellsite system ofFIG. 1 , aborehole 11 is formed in one or more subsurface formations F by rotary and/or directional drilling. - As illustrated in
FIG. 1 , adrill string 12 is suspended within theborehole 11 and has a bottom hole assembly (BHA) 100 having anoptional drill bit 105 at its lower end. A surface system includes a platform andderrick assembly 10 positioned over theborehole 11. Theexample derrick assembly 10 ofFIG. 1 includes a rotary table 16, akelly 17, ahook 18 and arotary swivel 19. Thedrill string 12 is rotated by the rotary table 16, energized by means not shown, which engages thekelly 17 at the upper end of thedrill string 12. Theexample drill string 12 is suspended from thehook 18, which is attached to a traveling block (not shown), and through thekelly 17 and therotary swivel 19, which permits rotation of thedrill string 12 relative to thehook 18. Additionally or alternatively, a top drive system could be used. - In the example of
FIG. 1 , the surface system further includes drilling fluid ormud 26 stored in apit 27 formed at the well site. Apump 29 delivers thedrilling fluid 26 to the interior of thedrill string 12 via a port in the swivel 19, causing the drilling fluid to flow downwardly through thedrill string 12 as indicated by thedirectional arrow 8. Thedrilling fluid 26 exits thedrill string 12 via ports in thedrill bit 105, and then circulates upwardly through the annulus region between the outside of thedrill string 12 and the wall of theborehole 11, as indicated by thedirectional arrows 9. Thedrilling fluid 26 lubricates thedrill bit 105, carries formation cuttings up to the surface as it is returned to thepit 27 for recirculation, and creates a mudcake layer on the walls of theborehole 11. - The example BHA 100 of
FIG. 1 includes, among other things, any number and/or type(s) of logging-while-drilling (LWD) modules (two of which are designated atreference numerals mud motor 150, and theoptional drill bit 105. - The
example LWD modules FIG. 1 are each housed in a special type of drill collar, as it is known in the art, and each contain any number of logging tools and/or fluid sampling devices. Theexample LWD modules control computer 160 via, for example, theMWD module 130. - An
example LWD module 200 having four packers to improve the accuracy and/or conditions in which pressure testing of the geological formation F may be performed is described below in connection withFIG. 2 . Example manners of implementing a pressure testing system 220 (FIG. 2 ) for any of theLWD modules FIGS. 3 and 5 . - Another example manner of implementing an
LWD module - The
example MWD module 130 ofFIG. 1 is also housed in a special type of drill collar and contains one or more devices for measuring characteristics of thedrill string 12 and/or thedrill bit 105. Theexample MWD tool 130 further includes an apparatus (not shown) for generating electrical power for use by the downhole system. Example devices to generate electrical power include, but are not limited to, a mud turbine generator powered by the flow of the drilling fluid, and a battery system. Example measuring devices include, but are not limited to, a weight-on-bit measuring device, a torque measuring device, a vibration measuring device, a shock measuring device, a stick slip measuring device, a direction measuring device, and an inclination measuring device. -
FIG. 2 is a schematic illustration of an example manner of implementing either or both of theexample LWD modules FIG. 1 . While either of theexample LWD modules FIG. 1 may be implemented by the example device ofFIG. 2 , for ease of discussion, the example device ofFIG. 2 will be referred to asLWD module 200. Theexample LWD module 200 ofFIG. 2 may be used to perform, among other things, pressure testing of a geological formation F. Theexample LWD module 200 is attached to the drill string 12 (FIG. 1 ) driven by therig 10 to form the wellbore orborehole 11. When theLWD module 200 is part of a drill string, theLWD module 200 includes a passage (not shown) to permit drilling mud to be pumped through theLWD module 200 to remove cuttings away from a drill bit. - To seal off intervals and/or
portions example wellbore 11, theexample LWD module 200 ofFIG. 2 includespackers FIG. 2 are inflatable elements that encircle the generally circularly shaped LWD 200. The example intervals 205-207 ofFIG. 2 likewise encircle theLWD 200. When inflated to form a seal with awall 215 of thewellbore 11, as shown inFIG. 2 , the example inner pair ofpackers sampling interval 205 in which pressure testing of the geological formation F is performed. Other formation and/or formation fluid tests and/or measurements may also be performed in theinner interval 205. When inflated to form a seal with thewall 215 of thewellbore 11, as shown inFIG. 2 , the example outer pair ofpackers respective guard intervals inner interval 205. The example packers 210-213 ofFIG. 2 have a height of 1.5 feet and a spacing of 3 feet. However, other size packers and/or packer spacing(s) may be used depending on an expected mud filtrate invasion depth, and/or a desired formation fluid cleanup and/or production performance. - To allow the example
pressure testing system 220 to be fluidly coupled to the intervals 205-207, theexample LWD module 200 ofFIG. 2 includesports FIGS. 3-5 , the examplepressure testing system 220 ofFIG. 2 is able to pump fluid from the sample and/orinner interval 205 via theport 225 to perform a cleanup or sampling operation of the sample interval 205 (e.g., lift and/or remove mudcake), and/or to drawdown the pressure in thesample interval 205 and measure subsequent pressure buildup data. The examplepressure testing system 220 is also able to draw fluid out of and/or push fluid into theguard intervals guard intervals pressure testing system 220 reduces the pressure in theguard intervals sample interval 205 is being drawn down to perform a pressure buildup test. In such an example, the pressure differential experienced by theinner packers 210 and 211 (seeFIG. 3 ) is reduced to less than the pressure differential that would be experienced by thepackers outer packers pressure testing system 220 ofFIG. 2 maintains the pressures in theguard intervals inner interval 205. By reducing and/or controlling the pressure differentials experienced by theinner packers inner packers inner packers FIG. 2 are subjected to lower differential pressures they may be implemented using simpler packer structures (e.g. shorter packers, packers having less or none reinforcement structures such as cables, etc.). The use of shorter and/or simpler packer structures may be advantageous to reduce the overall length of theLWD module 200. Example manners of implementing the examplepressure testing system 220 ofFIG. 2 is described below in connection withFIGS. 3 and 5 . - The example
pressure testing system 220 ofFIG. 2 is also fluidly coupled to aport 228 located below the exampleouter packer 213. Theexample port 228 ofFIG. 2 is directly exposed to the fluid(s) present in thewellbore 11. Theexample port 228 may, alternatively, be located above the exampleouter packer 212. Moreover, theport 228 may be fluidly coupled to an additional port (not shown) located above thepacker 212 via a bypass flowline of the LWD module 200 (not shown). Among other things, theexample port 228 ofFIG. 2 can be used to balance the pressure of the portion of thewellbore 11 located above thepacker 212 with the pressure of the portion of thewellbore 11 located below thepacker 213, and/or to allow fluid to be moved between any of the intervals 206-207 and thewellbore 11 via a bypass flowline of the LWD module 200 (not shown). - In some examples, one or more probes (not shown) having pretest capabilities may be implemented to perform formation pressure and/or mobility measurements in one or more of the
intervals outer packer 213 and/or above the exampleouter packer 212. Such probes may be used to obtain values representative of formation parameters in a substantially shorter time period than when using a packer interval. Formation parameter values obtained with the probe(s) may be used by examplepressure testing system 220 for example to maintain the pressures in theguard intervals - Additionally or alternatively, pressure values obtained with the probe(s) may be used to determine propagation properties of pressure pulses in the formation. Example manners of determining propagation properties of pressure pulses in the formation are taught for example in U.S. Pat. No. 4,936,139, entitled “Downhole Method for Determination of Formation Properties,” and issued on Jun. 26, 1990.
-
FIG. 3 illustrates an example manner of implementing the examplepressure testing system 220 ofFIG. 2 . To pump fluid from theinner interval 205 via theport 225, the examplepressure testing system 220 ofFIG. 2 includes any type ofpump 305. When activated, theexample pump 305 ofFIG. 3 pumps fluid from theport 225 into, for example, a sample container and/or bottle, the wellbore 11 (e.g., via a bypass flowline (not shown)), and/or a fluid analysis module. As shown inFIG. 4 , theexample pump 305 may be used to pump fluid from theinner interval 205 to drawdown the pressure PS of theinner interval 205 to initiate a pressure buildup test. In the example ofFIG. 4 , the inner interval pressure PS is reduced by thepump 305 to a pressure that is less than the formation pressure PF. In some examples, thepump 305 operates until a specified amount of reservoir fluid has been pumped. Additionally or alternatively, thepump 305 operates until the drawdown pressure is reached, thepump 305 is stopped, and the inner interval pressure PS is measured while it builds backup towards the formation pressure PF, and while the volume(s) of any flowlines and/or chambers fluidly coupled to theport 225 are held constant. To measure the inner interval pressure PS, the examplepressure testing system 220 ofFIG. 2 includes any type ofpressure gauge 310. - To adjust the pressure in the
guard intervals pressure testing system 220 ofFIG. 3 includes any type ofpump 315. Theexample pump 315 ofFIG. 3 is controllable to pump fluid into and/or out of theguard intervals guard intervals example pump 315 includes ahydraulic piston 320 to adjust the volume in achamber 325 fluidly coupled to theports guard intervals pressure testing system 220 ofFIG. 2 includes any type ofpressure gauge 330. To measure the pressure PW of thewellbore 11, the examplepressure testing system 220 ofFIG. 2 includes any type ofpressure gauge 335. In some examples, a single pump is used to implement thepump 305 and thepump 315. - To perform a pressure buildup test, the example
pressure testing system 220 ofFIG. 3 includes acontroller 340. Theexample controller 340 ofFIG. 3 controls theexample pump 305 andpiston 320 to initiate a pressure buildup test, and measures the pressure in theinner interval 205 during the subsequent pressure buildup phase via theexample pressure gauge 310. Theexample controller 340 also controls the inflation and deflation of the example packers 210-213. Theexample controller 340 ofFIG. 3 is implemented by any type of general-purpose processor, processor core, and/or microcontroller. Alternatively, theexample controller 340 may be implemented by one or more circuit(s), programmable processor(s), application specific integrated circuit(s) (ASIC(s)), programmable logic device(s) (PLD(s)) and/or field programmable logic device(s) (FPLD(s)), etc., and/or any combination of hardware, firmware and/or software. - As shown in
FIG. 4 , at atime 405 the example controller 340 (FIG. 3 ) activates thepump 305 to reduce the inner interval pressure PS from the wellbore pressure PW to a pressure less than the formation pressure PF. While the inner interval pressure PS is being reduced, theexample controller 340 adjusts the position of thepiston 320 to adjust the guard interval pressure PG to a desired and/or target pressure. The guard interval pressure PG may be adjusted in accordance with any number of pressure management strategies. For example, the guard interval pressure PG may be reduced to the formation pressure PF (e.g. estimated from a measurement performed by a probe). In such an example, the pressure differentials experienced by each of theinner packers outer packers inner packers outer packers example LWD module 200 can operate in a wellbore having a higher hydrostatic pressure to drawdown pressure difference than can be withstood by a single pair ofinner packers pump 305. Theexample controller 340 can determine how much to reduce the pressure PG of theguard intervals pressure gauge 335 and a desired drawdown pressure. For example, for a large wellbore to drawdown pressure difference, theexample controller 340 distributes the pressure difference across theouter packers inner packers example controller 340 adjusts the guard interval pressure PG to be substantially equal to the formation pressure PF. - When, at
time 410, the drawdown pressure has been reached and the guard interval pressure PG adjusted, thecontroller 340 starts measuring pressure buildup data in theinner interval 205 using thepressure gauge 310. -
FIG. 5 illustrates another example manner of implementing the examplepressure testing system 220 ofFIG. 2 . Because elements of the examplepressure testing system 220 ofFIG. 5 are similar or identical to those discussed above in connection withFIG. 3 , the descriptions of those similar or identical elements are not repeated here. Instead, similar or identical elements are illustrated with identical reference numerals inFIGS. 3 and 5 , and the interested reader is referred back to the descriptions presented above in connection withFIG. 3 for a complete description of those like numbered elements. - In contrast to the example
pressure testing system 220 ofFIG. 3 , the examplepressure testing system 220 ofFIG. 5 includespressure controllers guard intervals example pressure controller 505 ofFIG. 5 actively controls thepump 315 to maintain the guard interval pressure PG1 of theguard interval 206 based on the inner interval pressure PS and the wellbore pressure PW. For example, thepressure controller 505 adapts and/or maintains the guard interval pressure PG1 to be substantially equal to the inner interval pressure PS to reduce the mechanical stresses experienced by theinner packer 210. When the wellbore to drawdown pressure difference is large, theexample controller 505 adapts the guard interval pressure PG1 to distribute the pressure difference between theouter packer 212 and theinner packer 210. The pressure PG1 of theguard interval 206 is measured by theexample pressure gauge 330. - Likewise, the
example pressure controller 510 ofFIG. 5 actively controls apump 315B, which is substantially identical to theexample pump 315, to maintain the guard interval pressure PG2 of thesecond guard interval 207 based on the inner interval pressure PS and the wellbore pressure PW. The pressure PG2 of theguard interval 207 is measured by apressure gauge 330B, which is substantially identical to thepressure gauge 330. While in some examples, the pressures PG1 and PG1 are maintained at substantially the same pressure, the pressures PG1 and PG1 may be maintained at different pressures. For example, independent control of the pressure PG1 in thefirst guard interval 206 and the pressure PG2 in thesecond guard interval 207 may be beneficial when one of theouter packers guard intervals outer packer testing interval 205. - The
example pressure controllers FIG. 5 are implemented by any type of general-purpose processor, processor core, and/or microcontroller. Alternatively, theexample pressure controllers - In addition to controlling the
example pump 305 and measuring the pressure buildup data via theexample pressure gauge 310, as described above in connection withFIGS. 3 and 4 , theexample controller 340 ofFIG. 5 activates and/or deactivates thepressure controllers - While example manners of implementing the example
pressure testing system 220 ofFIG. 2 have been illustrated inFIGS. 3 and 5 , one or more of the elements, controllers and/or devices illustrated inFIGS. 3 and/or 5 may be combined, divided, re-arranged, omitted, eliminated, and/or implemented in any other way. For example, theexample pressure controller 505 could be implemented in the examplepressure control system 220 ofFIG. 2 to adapt, control and/or maintain the pressure in both of theguard intervals pump 315. Further, a pressure testing system and/or LWD module may include elements, controllers and/or devices instead of, or in addition to, those illustrated inFIGS. 3 and/or 5, and/or may include more than one of any or all of the illustrated elements, controllers and/or devices. -
FIG. 6 illustrates an example process that may be carried out to perform pressure testing of a geological formation. The example process ofFIG. 6 may be carried out by a processor, a controller and/or any other suitable processing device. For example, the process ofFIG. 6 may be embodied in coded instructions stored on a tangible machine and/or computer-readable medium such as a flash memory, a CD, a DVD, a floppy disk, a read-only memory (ROM), a random-access memory (RAM), a programmable ROM (PROM), an electronically-programmable ROM (EPROM), and/or an electronically-erasable PROM (EEPROM), an optical storage disk, an optical storage device, a magnetic storage disk, a magnetic storage device, and/or any other tangible medium, which can be accessed, read and/or executed by a processor, a general purpose or special purpose computer or other machine with a processor (e.g., the example processor platform P100 discussed below in connection withFIG. 7 ). Alternatively, some or all of the example process ofFIG. 6 may be implemented using any combination(s) of circuit(s), ASIC(s), PLD(s), FPLD(s), discrete logic, hardware, firmware, etc. Also, some or all of the example process ofFIG. 6 may be implemented manually or as any combination of any of the foregoing techniques, for example, any combination of firmware, software, discrete logic and/or hardware. Further, although the example operations ofFIG. 6 are described with reference to the flowchart ofFIG. 6 , many other methods of implementing the operations ofFIG. 6 may be employed. For example, the order of execution of the blocks may be changed, and/or one or more of the blocks described may be changed, eliminated, sub-divided, or combined. Additionally, any or all of the example process ofFIG. 6 may be carried out sequentially and/or carried out in parallel by, for example, separate processing threads, processors, devices, discrete logic, circuits, etc. - The example process of
FIG. 6 begins with theexample LWD module 200 ofFIG. 2 being positioned in a wellbore (block 605). The example controller 340 (FIGS. 3 and 5 ) inflates the packers 210-213 to seal and/or form the intervals 205-207 (block 610). In some examples, theinner packers outer packers - In some examples, the
controller 340 collects pressure data to estimate the wellbore pressure PW and the formation pressure PF. For example, the wellbore pressure PW may be obtained via the pressure sensor 335 (FIGS. 3 and 5 ), and thecontroller 340 may initiate a pretest using a probe (not shown) to estimate the formation pressure PF. In other examples, prior knowledge of the formation F (e.g. from a remotely performed pressure test, a pressure gradient, etc.) are used estimate the formation pressure PF. - The
controller 340 activates thepump 305 to, for example, perform initial cleanup, and/or mudcake removal in the inner interval 205 (block 615). In some example implementations, such as when no formation pressure estimate has been obtained otherwise, a formation pressure estimation may also be obtained atblock 615 by detecting a mudcake breach and/or by permitting the pressure PS in theinterval 205 to stabilize after mudcake removal. - The
controller 340 activates thepump 305 to drawdown the pressure PS of the inner interval 205 (block 620). At substantially the same time, thecontroller 340 ofFIG. 35 controls thepump 315 or activates thepressure controllers 505 and 510 (FIG. 5 ) to adjust, set and/or otherwise reduce the pressures PG1 and/or PG2 of theguard intervals 206 and 207 (block 625). Alternatively, if thepressure testing system 220 ofFIG. 3 is being used, atblock 625 theexample controller 340 controls thepump 315 to adjust, set and/or otherwise reduce the pressure PG of theguard intervals outer intervals FIG. 2 ), which could have negative effect on the quality of the pressure buildup data and their interpretation. The drawdown and the guard interval pressure reductions may be performed in parallel to maintain the mechanical stability of the inner packers 210-211. Thecontroller 340 then freezes and/or fixes the volume of any flowlines and/or chambers fluidly coupled to the sample interval 205 (block 630). - If the
pressure controllers guard intervals 206 and 207 (block 635), thecontroller 340 measures the pressure buildup data using thepressure gauge 310, seeFIG. 3 (block 640). If there arepressure controllers guard intervals 206 and 207 (block 635), thecontroller 340 measures the pressure buildup data using thepressure gauge 310 while thepressure controllers FIG. 5 (block 645). - When the pressure buildup test is complete, the
controller 340 stores the measured pressure buildup data (block 650), and de-activates thepressure controllers 505 and 510 (if present) and deflates the packers (block 655). Control then exits from the example process ofFIG. 6 . Alternatively, atblock 610 only theinner packers block 615, theouter packers -
FIG. 7 is a schematic diagram of an example processor platform P100 that may be used and/or programmed to implement any or all of the example methods and apparatus disclosed herein. For example, the processor platform P100 can be implemented by one or more general-purpose processors, processor cores, microcontrollers, etc. - The processor platform P100 of the example of
FIG. 7 includes at least one general-purpose programmable processor P105. The processor P105 executes coded instructions P110 and/or P112 present in main memory of the processor P105 (e.g., within a RAM P115 and/or a ROM P120). The processor P105 may be any type of processing unit, such as a processor core, a processor and/or a microcontroller. The processor P105 may execute, among other things, the example process ofFIG. 6 to perform pressure testing of a geological formation. - The processor P105 is in communication with the main memory (including a ROM P120 and/or the RAM P115) via a bus P125. The RAM P115 may be implemented by dynamic random-access memory (DRAM), synchronous dynamic random-access memory (SDRAM), and/or any other type of RAM device(s), and ROM may be implemented by flash memory, EPROM, EEPROM, a CD, a DVD and/or any other desired type of memory device(s). Access to the memory P115 and the memory P120 may be controlled by a memory controller (not shown). The memory P115 may be used to store pressure buildup data.
- The processor platform P100 also includes an interface circuit P130. The interface circuit P130 may be implemented by any type of interface standard, such as an external memory interface, serial port, general-purpose input/output, etc. One or more input devices P135 and one or more output devices P140 are connected to the interface circuit P130. The input devices P135 may be used to collect and/or receive pressure data from a pressure gauge. The output devices P140 may be use to control and/or activate a pump.
- Although certain example methods, apparatus and articles of manufacture have been described herein, the scope of coverage of this patent is not limited thereto. On the contrary, this patent covers all methods, apparatus and articles of manufacture fairly falling within the scope of the appended claims either literally or under the doctrine of equivalents.
Claims (21)
Priority Applications (7)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/202,868 US8015869B2 (en) | 2008-09-02 | 2008-09-02 | Methods and apparatus to perform pressure testing of geological formations |
EG2009081248A EG25940A (en) | 2008-09-02 | 2009-08-19 | Methods and apparatus to perform pressure testing of geological formations |
BRPI0902663-0A BRPI0902663A2 (en) | 2008-09-02 | 2009-08-20 | pressure test method of a geological formation, background tool for pressure test of a geological formation |
GB0914525A GB2462911B (en) | 2008-09-02 | 2009-08-20 | Methods and apparatus to perform pressure testing of geological formations |
MX2009009161A MX2009009161A (en) | 2008-09-02 | 2009-08-27 | Methods and apparatus to perform pressure testing of geological formations. |
MYPI20093613A MY147671A (en) | 2008-09-02 | 2009-09-01 | Methods and apparatus to perform pressure testing of geological formations |
NO20092918A NO20092918L (en) | 2008-09-02 | 2009-09-01 | Methods and apparatus for performing pressure testing of geological formations |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/202,868 US8015869B2 (en) | 2008-09-02 | 2008-09-02 | Methods and apparatus to perform pressure testing of geological formations |
Publications (2)
Publication Number | Publication Date |
---|---|
US20100050762A1 true US20100050762A1 (en) | 2010-03-04 |
US8015869B2 US8015869B2 (en) | 2011-09-13 |
Family
ID=41171635
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US12/202,868 Active 2030-03-27 US8015869B2 (en) | 2008-09-02 | 2008-09-02 | Methods and apparatus to perform pressure testing of geological formations |
Country Status (7)
Country | Link |
---|---|
US (1) | US8015869B2 (en) |
BR (1) | BRPI0902663A2 (en) |
EG (1) | EG25940A (en) |
GB (1) | GB2462911B (en) |
MX (1) | MX2009009161A (en) |
MY (1) | MY147671A (en) |
NO (1) | NO20092918L (en) |
Cited By (15)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US8015869B2 (en) * | 2008-09-02 | 2011-09-13 | Schlumberger Technology Corporation | Methods and apparatus to perform pressure testing of geological formations |
WO2012129389A3 (en) * | 2011-03-23 | 2012-12-27 | Schlumberger Canada Limited | Measurement pretest drawdown methods and apparatus |
US20150007985A1 (en) * | 2013-07-03 | 2015-01-08 | Schlumberger Technology Corporation | Packer-Packer Vertical Interference Testing |
WO2016019824A1 (en) * | 2014-08-04 | 2016-02-11 | 王恩元 | Multipoint coal and rock mass stress real-time monitoring device and method |
US20170090457A1 (en) * | 2015-09-30 | 2017-03-30 | Baker Hughes Incorporated | Pump integrity detection, monitoring and alarm generation |
WO2017196303A1 (en) * | 2016-05-10 | 2017-11-16 | Halliburton Energy Services Inc. | Tester valve below a production packer |
US10795044B2 (en) * | 2017-03-31 | 2020-10-06 | Halliburton Energy Services, Inc. | Downhole, real-time determination of relative permeability with nuclear magnetic resonance and formation testing measurements |
CN112714820A (en) * | 2018-09-14 | 2021-04-27 | 埃尼股份公司 | Method for estimating pore pressure value in geological structure to be drilled through drilling equipment |
CN114026467A (en) * | 2019-06-24 | 2022-02-08 | 埃尼股份公司 | Detection system for detecting anomalies in discontinuous interface and/or pore pressure in a geological formation |
CN114112181A (en) * | 2021-11-26 | 2022-03-01 | 山东科技大学 | Wireless stress monitoring acousto-optic early warning instrument and monitoring early warning method |
US11359480B2 (en) * | 2019-05-31 | 2022-06-14 | Halliburton Energy Services, Inc. | Pressure measurement supercharging mitigation |
US11506050B2 (en) * | 2019-12-27 | 2022-11-22 | Adams Testing Service, Inc. | Hydraulic pressure testing system, and method of testing tubular products |
CN117418798A (en) * | 2023-12-19 | 2024-01-19 | 东北石油大学三亚海洋油气研究院 | Intelligent drilling fluid injection adjusting method, device and system |
CN117927749A (en) * | 2024-03-22 | 2024-04-26 | 胜利油田胜机石油装备有限公司 | Novel heat insulation coupling for heat insulation pipe |
US12000268B2 (en) | 2022-11-21 | 2024-06-04 | Adams Testing Services, Inc. | Hydraulic pressure testing system, and method of testing tubular products |
Families Citing this family (14)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US9238961B2 (en) | 2009-10-05 | 2016-01-19 | Schlumberger Technology Corporation | Oilfield operation using a drill string |
EP2486237A4 (en) | 2009-10-05 | 2017-04-26 | Schlumberger Technology B.V. | Formation testing |
BR112012007730A2 (en) | 2009-10-06 | 2016-08-23 | Prad Res & Dev Ltd | training test planning and monitoring |
CN102121377B (en) * | 2011-01-05 | 2013-07-31 | 中国海洋石油总公司 | Pressure-while-drilling measuring device and measurement method thereof |
US8905130B2 (en) * | 2011-09-20 | 2014-12-09 | Schlumberger Technology Corporation | Fluid sample cleanup |
US9062544B2 (en) * | 2011-11-16 | 2015-06-23 | Schlumberger Technology Corporation | Formation fracturing |
KR101460029B1 (en) * | 2013-05-02 | 2014-11-10 | 한국지질자원연구원 | Method for connectivity test between vertical formations while drilling |
US9759055B2 (en) * | 2013-12-18 | 2017-09-12 | Schlumberger Technology Corporation | Formation fracturing and sampling methods |
US9976402B2 (en) * | 2014-09-18 | 2018-05-22 | Baker Hughes, A Ge Company, Llc | Method and system for hydraulic fracture diagnosis with the use of a coiled tubing dual isolation service tool |
US9708906B2 (en) | 2014-09-24 | 2017-07-18 | Baker Hughes Incorporated | Method and system for hydraulic fracture diagnosis with the use of a coiled tubing dual isolation service tool |
US10704369B2 (en) * | 2017-06-22 | 2020-07-07 | Saudi Arabian Oil Company | Simultaneous injection and fracturing interference testing |
CN108729905A (en) * | 2018-04-20 | 2018-11-02 | 中国石油天然气股份有限公司 | A kind of rod-pumped well crosses annular space docking monitoring and adjusts automatically controlled water plugging string |
RU2761909C1 (en) * | 2021-01-11 | 2021-12-14 | Общество с ограниченной ответственностью "Газпром добыча Уренгой" | Method for pressure testing of operational casing column of idle well |
US11913329B1 (en) | 2022-09-21 | 2024-02-27 | Saudi Arabian Oil Company | Untethered logging devices and related methods of logging a wellbore |
Citations (10)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3323360A (en) * | 1963-08-13 | 1967-06-06 | Schlumberger Technology Corp | Methods and apparatus for analyzing well production |
US4353249A (en) * | 1980-10-30 | 1982-10-12 | Systems, Science And Software | Method and apparatus for in situ determination of permeability and porosity |
US4936139A (en) * | 1988-09-23 | 1990-06-26 | Schlumberger Technology Corporation | Down hole method for determination of formation properties |
US5831156A (en) * | 1997-03-12 | 1998-11-03 | Mullins; Albert Augustus | Downhole system for well control and operation |
US6301959B1 (en) * | 1999-01-26 | 2001-10-16 | Halliburton Energy Services, Inc. | Focused formation fluid sampling probe |
US6478096B1 (en) * | 2000-07-21 | 2002-11-12 | Baker Hughes Incorporated | Apparatus and method for formation testing while drilling with minimum system volume |
US6986282B2 (en) * | 2003-02-18 | 2006-01-17 | Schlumberger Technology Corporation | Method and apparatus for determining downhole pressures during a drilling operation |
US7031841B2 (en) * | 2004-01-30 | 2006-04-18 | Schlumberger Technology Corporation | Method for determining pressure of earth formations |
US20100024540A1 (en) * | 2006-09-18 | 2010-02-04 | Ricardo Vasques | Adjustable testing tool and method of use |
US20100319912A1 (en) * | 2009-06-18 | 2010-12-23 | Pop Julian J | Focused sampling of formation fluids |
Family Cites Families (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3871218A (en) | 1972-08-25 | 1975-03-18 | Anvar | Method and apparatus for determining the permeability characteristics of a porous or fissured medium |
US4392376A (en) | 1981-03-31 | 1983-07-12 | S-Cubed | Method and apparatus for monitoring borehole conditions |
CN1317484C (en) | 2003-09-19 | 2007-05-23 | 吴孝喜 | Cavity water sampling and generating method for oil well in production |
US8015869B2 (en) * | 2008-09-02 | 2011-09-13 | Schlumberger Technology Corporation | Methods and apparatus to perform pressure testing of geological formations |
CN101403293B (en) | 2008-11-11 | 2012-06-06 | 大庆油田有限责任公司 | Column type down-hole shut-in well delamination pressure test technique suitable for oil well |
-
2008
- 2008-09-02 US US12/202,868 patent/US8015869B2/en active Active
-
2009
- 2009-08-19 EG EG2009081248A patent/EG25940A/en active
- 2009-08-20 BR BRPI0902663-0A patent/BRPI0902663A2/en active Search and Examination
- 2009-08-20 GB GB0914525A patent/GB2462911B/en not_active Expired - Fee Related
- 2009-08-27 MX MX2009009161A patent/MX2009009161A/en active IP Right Grant
- 2009-09-01 MY MYPI20093613A patent/MY147671A/en unknown
- 2009-09-01 NO NO20092918A patent/NO20092918L/en not_active Application Discontinuation
Patent Citations (11)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3323360A (en) * | 1963-08-13 | 1967-06-06 | Schlumberger Technology Corp | Methods and apparatus for analyzing well production |
US4353249A (en) * | 1980-10-30 | 1982-10-12 | Systems, Science And Software | Method and apparatus for in situ determination of permeability and porosity |
US4936139A (en) * | 1988-09-23 | 1990-06-26 | Schlumberger Technology Corporation | Down hole method for determination of formation properties |
US5831156A (en) * | 1997-03-12 | 1998-11-03 | Mullins; Albert Augustus | Downhole system for well control and operation |
US6301959B1 (en) * | 1999-01-26 | 2001-10-16 | Halliburton Energy Services, Inc. | Focused formation fluid sampling probe |
US6478096B1 (en) * | 2000-07-21 | 2002-11-12 | Baker Hughes Incorporated | Apparatus and method for formation testing while drilling with minimum system volume |
US6986282B2 (en) * | 2003-02-18 | 2006-01-17 | Schlumberger Technology Corporation | Method and apparatus for determining downhole pressures during a drilling operation |
US7031841B2 (en) * | 2004-01-30 | 2006-04-18 | Schlumberger Technology Corporation | Method for determining pressure of earth formations |
US20100024540A1 (en) * | 2006-09-18 | 2010-02-04 | Ricardo Vasques | Adjustable testing tool and method of use |
US7913557B2 (en) * | 2006-09-18 | 2011-03-29 | Schlumberger Technology Corporation | Adjustable testing tool and method of use |
US20100319912A1 (en) * | 2009-06-18 | 2010-12-23 | Pop Julian J | Focused sampling of formation fluids |
Cited By (25)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US8015869B2 (en) * | 2008-09-02 | 2011-09-13 | Schlumberger Technology Corporation | Methods and apparatus to perform pressure testing of geological formations |
WO2012129389A3 (en) * | 2011-03-23 | 2012-12-27 | Schlumberger Canada Limited | Measurement pretest drawdown methods and apparatus |
CN103717834A (en) * | 2011-03-23 | 2014-04-09 | 普拉德研究及开发股份有限公司 | Measurement pretest drawdown methods and apparatus |
US9581019B2 (en) | 2011-03-23 | 2017-02-28 | Schlumberger Technology Corporation | Measurement pretest drawdown methods and apparatus |
US9714570B2 (en) * | 2013-07-03 | 2017-07-25 | Schlumberger Technology Corporation | Packer-packer vertical interference testing |
US20150007985A1 (en) * | 2013-07-03 | 2015-01-08 | Schlumberger Technology Corporation | Packer-Packer Vertical Interference Testing |
US10082433B2 (en) | 2014-08-04 | 2018-09-25 | China University Of Mining And Technology | Multipoint coal and rock mass stress real-time monitoring device and method |
WO2016019824A1 (en) * | 2014-08-04 | 2016-02-11 | 王恩元 | Multipoint coal and rock mass stress real-time monitoring device and method |
US20170090457A1 (en) * | 2015-09-30 | 2017-03-30 | Baker Hughes Incorporated | Pump integrity detection, monitoring and alarm generation |
US10317875B2 (en) * | 2015-09-30 | 2019-06-11 | Bj Services, Llc | Pump integrity detection, monitoring and alarm generation |
WO2017196303A1 (en) * | 2016-05-10 | 2017-11-16 | Halliburton Energy Services Inc. | Tester valve below a production packer |
US11105179B2 (en) | 2016-05-10 | 2021-08-31 | Halliburton Energy Services, Inc. | Tester valve below a production packer |
US10795044B2 (en) * | 2017-03-31 | 2020-10-06 | Halliburton Energy Services, Inc. | Downhole, real-time determination of relative permeability with nuclear magnetic resonance and formation testing measurements |
CN112714820A (en) * | 2018-09-14 | 2021-04-27 | 埃尼股份公司 | Method for estimating pore pressure value in geological structure to be drilled through drilling equipment |
US11852010B2 (en) | 2018-09-14 | 2023-12-26 | Eni S.P.A. | Method for estimating a pore pressure value in geological formations to be drilled by a drilling apparatus |
US11359480B2 (en) * | 2019-05-31 | 2022-06-14 | Halliburton Energy Services, Inc. | Pressure measurement supercharging mitigation |
US11655705B2 (en) | 2019-05-31 | 2023-05-23 | Halliburton Energy Services, Inc. | Pressure measurement mitigation |
US11686193B2 (en) | 2019-05-31 | 2023-06-27 | Halliburton Energy Services, Inc. | Pressure measurement mitigation |
CN114026467A (en) * | 2019-06-24 | 2022-02-08 | 埃尼股份公司 | Detection system for detecting anomalies in discontinuous interface and/or pore pressure in a geological formation |
US11860328B2 (en) | 2019-06-24 | 2024-01-02 | Eni S.P.A. | Detection system for detecting discontinuity interfaces and/or anomalies in pore pressures in geological formations |
US11506050B2 (en) * | 2019-12-27 | 2022-11-22 | Adams Testing Service, Inc. | Hydraulic pressure testing system, and method of testing tubular products |
CN114112181A (en) * | 2021-11-26 | 2022-03-01 | 山东科技大学 | Wireless stress monitoring acousto-optic early warning instrument and monitoring early warning method |
US12000268B2 (en) | 2022-11-21 | 2024-06-04 | Adams Testing Services, Inc. | Hydraulic pressure testing system, and method of testing tubular products |
CN117418798A (en) * | 2023-12-19 | 2024-01-19 | 东北石油大学三亚海洋油气研究院 | Intelligent drilling fluid injection adjusting method, device and system |
CN117927749A (en) * | 2024-03-22 | 2024-04-26 | 胜利油田胜机石油装备有限公司 | Novel heat insulation coupling for heat insulation pipe |
Also Published As
Publication number | Publication date |
---|---|
EG25940A (en) | 2012-11-05 |
MX2009009161A (en) | 2010-04-30 |
US8015869B2 (en) | 2011-09-13 |
BRPI0902663A2 (en) | 2010-08-03 |
MY147671A (en) | 2012-12-31 |
NO20092918L (en) | 2010-03-03 |
GB2462911B (en) | 2011-05-25 |
GB2462911A (en) | 2010-03-03 |
GB0914525D0 (en) | 2009-09-30 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US8015869B2 (en) | Methods and apparatus to perform pressure testing of geological formations | |
US6672386B2 (en) | Method for in-situ analysis of formation parameters | |
US9303508B2 (en) | In-situ stress measurements in hydrocarbon bearing shales | |
US7124819B2 (en) | Downhole fluid pumping apparatus and method | |
US6568487B2 (en) | Method for fast and extensive formation evaluation using minimum system volume | |
AU777211C (en) | Closed-loop drawdown apparatus and method for in-situ analysis of formation fluids | |
US7032661B2 (en) | Method and apparatus for combined NMR and formation testing for assessing relative permeability with formation testing and nuclear magnetic resonance testing | |
US9222352B2 (en) | Control of a component of a downhole tool | |
US10480316B2 (en) | Downhole fluid analysis methods for determining viscosity | |
US9399913B2 (en) | Pump control for auxiliary fluid movement | |
US9714570B2 (en) | Packer-packer vertical interference testing | |
US8534115B2 (en) | Systems and methods of determining parameter values in a downhole environment | |
US7954252B2 (en) | Methods and apparatus to determine and use wellbore diameters | |
US11466567B2 (en) | High flowrate formation tester | |
US8826977B2 (en) | Remediation of relative permeability blocking using electro-osmosis | |
US12006822B2 (en) | High flowrate formation tester | |
CA2424112C (en) | A method and apparatus for combined nmr and formation testing for assessing relative permeability with formation testing and nuclear magnetic resonance testing |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
AS | Assignment |
Owner name: SCHLUMBERGER TECHNOLOGY CORPORATION,TEXAS Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:NOLD, RAYMOND V., III;ZAZOVSKY, ALEXANDER F.;LANDSIEDEL, NATHAN;AND OTHERS;SIGNING DATES FROM 20080903 TO 20081103;REEL/FRAME:021776/0879 Owner name: SCHLUMBERGER TECHNOLOGY CORPORATION, TEXAS Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:NOLD, RAYMOND V., III;ZAZOVSKY, ALEXANDER F.;LANDSIEDEL, NATHAN;AND OTHERS;SIGNING DATES FROM 20080903 TO 20081103;REEL/FRAME:021776/0879 |
|
STCF | Information on status: patent grant |
Free format text: PATENTED CASE |
|
FPAY | Fee payment |
Year of fee payment: 4 |
|
MAFP | Maintenance fee payment |
Free format text: PAYMENT OF MAINTENANCE FEE, 8TH YEAR, LARGE ENTITY (ORIGINAL EVENT CODE: M1552); ENTITY STATUS OF PATENT OWNER: LARGE ENTITY Year of fee payment: 8 |
|
MAFP | Maintenance fee payment |
Free format text: PAYMENT OF MAINTENANCE FEE, 12TH YEAR, LARGE ENTITY (ORIGINAL EVENT CODE: M1553); ENTITY STATUS OF PATENT OWNER: LARGE ENTITY Year of fee payment: 12 |